WO2011095542A2 - Procédé d'extraction par injection de solvant - Google Patents

Procédé d'extraction par injection de solvant Download PDF

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Publication number
WO2011095542A2
WO2011095542A2 PCT/EP2011/051554 EP2011051554W WO2011095542A2 WO 2011095542 A2 WO2011095542 A2 WO 2011095542A2 EP 2011051554 W EP2011051554 W EP 2011051554W WO 2011095542 A2 WO2011095542 A2 WO 2011095542A2
Authority
WO
WIPO (PCT)
Prior art keywords
solvent
well
wells
hydrocarbon
mixture
Prior art date
Application number
PCT/EP2011/051554
Other languages
English (en)
Other versions
WO2011095542A3 (fr
Inventor
Jostein Alvestad
Aurelie Lagisquet
Eimund Gilje
Original Assignee
Statoil Asa
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Statoil Asa filed Critical Statoil Asa
Priority to US13/576,956 priority Critical patent/US9115577B2/en
Priority to EA201290752A priority patent/EA029061B1/ru
Publication of WO2011095542A2 publication Critical patent/WO2011095542A2/fr
Publication of WO2011095542A3 publication Critical patent/WO2011095542A3/fr
Priority to US14/801,088 priority patent/US10190400B2/en

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Classifications

    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
    • E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
    • E21B43/2406—Steam assisted gravity drainage [SAGD]
    • E21B43/2408—SAGD in combination with other methods
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/592—Compositions used in combination with generated heat, e.g. by steam injection

Definitions

  • the present invention relates to a solvent injection method for recovery of bitumen and extra heavy oil (EHO).
  • Recent recovery methods include steam assisted gravity drainage (SAGD) and the solvent co-injection variant thereof.
  • SAGD steam assisted gravity drainage
  • Another method is the so-called N-Solv process.
  • SAGD (Albahlani, A.M., Babadagli, T., "A Critical review of the Status of SAGD: Where Are We and What is Next?", SPE 1 13283, 2008 SPE Western Regional, Bakersfield California) is a method of recovering bitumen and EHO which dates back to the 1960's.
  • a pair of wells is drilled, one above the other.
  • the upper well is used to inject steam, optionally with a solvent.
  • the lower well is used to collect the hot bitumen or EHO and condensed water from the steam.
  • the injected steam forms a chamber that grows within the formation. The steam heats the oil/bitumen and reduces its viscosity so that it can flow into the lower well.
  • the solvent co-injection variant of the SAGD process (Gupta, S., Gittins, S., Picherack, P., "Insights Into Some Key Issues With Solvent Aided Process", JCPT, February 2003, Vol 43, No 2) aims to improve the performance of SAGD by introducing hydrocarbon solvent additives to the injected steam.
  • the operating conditions for the solvent co- injection process are similar to SAGD.
  • N-Solv process Neenniger, J.E., Gunnewiek, L, "Dew Point vs Bubble Point: A Misunderstood Constraint on Gravity Drainage Processes", CI PC 2009, paper 065; Nenniger, J.E., Dunn, S.G.
  • the present invention provides a process for the recovery of hydrocarbons from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, wherein there is hydraulic communication between said wells, the method comprising the steps: injecting one of more hydrocarbon solvents into the upper injection well at or above critical temperature of the solvent or solvent mixture, thereby causing a mixture of hydrocarbons and solvent to collect in the lower production well; and extracting the hydrocarbons from the lower production well.
  • the present invention also provides a process for the recovery of hydrocarbons from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well wherein there is hydraulic communication between said wells, the method comprising the steps: injecting one of more hydrocarbon solvents into the upper injection well so that the temperature of the solvent or solvent mixture in the upper injection well is 90°C or more, thereby causing a mixture of hydrocarbons and solvent to collect in the lower production well; and extracting the hydrocarbons from the lower production well.
  • a first aspect of the present invention provides a process for the recovery of hydrocarbons from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the steps: preheating an area around and between the wells by circulating hot solvent through at least part of both of the wells until hydraulic communication between both wells is achieved; injecting one of more hydrocarbon solvents into the upper injection well at or above critical temperature of the solvent or solvent mixture, thereby causing a mixture of hydrocarbons and solvent to collect in the lower production well; and extracting the hydrocarbons from the lower production well.
  • a second aspect of the present invention provides a process for the recovery of hydrocarbons from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the steps: preheating an area around and between the wells by circulating hot solvent through the completed interval of each of the wells until hydraulic communication between both wells is achieved; injecting one of more hydrocarbon solvents into the upper injection well so that the temperature of the solvent or solvent mixture in the upper injection well is 90°C or more, thereby causing a mixture of hydrocarbons and solvent to collect in the lower production well; and extracting the hydrocarbons from the lower production well.
  • a third aspect of the present invention provides a process for the recovery of hydrocarbons from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the following steps: preheating an area around and between the wells by circulating hot solvent through at least part of both of the wells until sufficient hydraulic communication between both wells is achieved; injecting one or more hydrocarbon solvents into the upper injection well at or above critical temperature of the solvent or solvent mixture, thereby:
  • a fourth aspect of the present invention provides a process for the recovery of hydrocarbons from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the steps: preheating the region between the wells by circulating hot solvent through at least part of both of the wells until hydraulic communication between both wells is achieved; injecting one or more hydrocarbon solvents into the upper injection well so that the temperature of the solvent or solvent mixture within the upper injection well is 90°C or more, thereby:
  • the N-Solv process operates at low temperatures (typically up to 70 °C,) and uses propane as the preferred solvent. This can result in low drainage rates.
  • SAGD and SAGD with solvent co-injection operate above 200 °C so the energy usage is high.
  • the present invention preferably injects the hydrocarbon solvent or solvent mixture at a temperature of 90°C to 400°C, more preferably at a temperature of 150°C to 300°C. No steam is utilised in the process.
  • Typical solvents are the lower alkanes, with butane or pentane being preferred.
  • the present invention offers lower energy utilisation rates and does not require any use of water. C0 2 emissions are also considerably lower.
  • the present invention also achieves faster oil drainage rates than the N-Solv process due to employing a significantly higher solvent chamber temperature than N-Solv extraction temperature. De-asphalting of the bitumen/EHO at the boundary layer between the solvent chamber and the bitumen/EHO region can occur also in the high temperature solvent injection process of the present invention.
  • the present invention is a gravity-based thermal recovery process of bitumen and extra heavy oil.
  • a preferred class of embodiments of this recovery process entails use of a pair of substantially parallel horizontal wells, located above each other, at a vertical distance of typically from 2 to 20 metres, say 5 metres, placed at the bottom of the reservoir.
  • the area around and between the wells is heated by circulating hot solvent through the completed interval of each of the wells until sufficient hydraulic communication between the wells is achieved. After the pre-heating period is finished the upper well is converted to an injector and the bottom well to a producer.
  • a hydrocarbon solvent (or mixture of hydrocarbon solvents) of technical grade is injected in the upper well at or above critical temperature.
  • a mixture of bitumen/EHO and solvent is produced through the bottom well.
  • the solvent is separated from the produced well stream and recycled. At the end of the production period, the solvent is back produced by means of injection of non-condensable gases and pressure reduction.
  • a non-condensable gas (which is less dense than the solvent / solvent mixture) is injected in the injection well, and displaces the solvent / solvent mixture by gravity driven flooding process.
  • the solvent / solvent mixture and the injected non-condensable gas are produced through the producer well.
  • the non-condensable gas is separated from the solvent / solvent mixture at the surface and re-injected until sufficient recovery of the solvent / solvent mixture is achieved.
  • bitumen/EHO is heated by conduction to the solvent temperature in the vicinity of the solvent interface (typically a few meters),
  • Typical solvents usable in this process of the present invention are lower alkanes, such as propane, butane or pentane, but not limited to these, and mixtures thereof.
  • Butane or pentane are the solvents of choice providing good solubility and an optimum operating temperature for the process.
  • the solvent is heavier than other solvents used in the prior art, such as propane, and this provides increased solubility in the bitumen but higher injection temperatures are required, beyond the critical temperature of the solvent, due to higher condensation temperature.
  • the critical temperature of a solvent or solvent mixture is readily obtainable from standard texts.
  • typical operating well temperature ranges for the process of the present invention are, particularly for the solvents listed, in the range of 90 - 400 °C, more preferably 150°C to 300°C.
  • the solvent injection rate is adjusted to the reservoir (chamber) properties.
  • the gas is injected at a pressure of below 40 bars (approx. critical pressure of butane).
  • Optimum operating pressures are between 8-25 bars, more specifically 15 to 25 bars for butane and 8 to 25 bars for pentane, to provide an optimal temperature range for the process.
  • the pressure operating range will depend upon the solvent selected.
  • Figure 1A shows a vertical cross section perpendicular to the horizontal well pair used in a recovery process according to the present invention, viewed along the wells;
  • Figure 1 B shows an expanded detail of the solvent chamber - bitumen/EHO transition region;
  • Figure 2 is a plot of Pressure against Temperature illustrating the phase behaviour and the critical temperature of a substance
  • Figure 3 is a schematic diagram of a physical model used to verify the recovery process according to one embodiment of the present invention.
  • Figure 1A shows a vertical section perpendicular to the horizontal well pair used in a recovery process according to the present invention.
  • the outer boundary of the solvent chamber is denoted by reference numeral 3.
  • a production well Situated below the upper well 1 is a production well 5. Hot solvent in vapour form is injected into the upper injection well 1 as denoted by arrows 7.
  • bitumen/EHO flows (9) into the well. Injection of hydrocarbon solvents as mentioned above causes a mixture of bitumen/EHO and solvent to: - drain downwards by gravity and sideways by pressure gradient to the lower well and
  • the solvent can be recovered for recycling.
  • Figure 1 B shows an expanded detail of the solvent chamber - bitumen/EHO transition region. Solubilisation of solvent into the bitumen/EHO occurs by diffusive and convective mixing in the solvent chamber - bitumen/EHO transition region. The bitumen/EHO is de-asphalted in the presence of higher solvent concentration. As a result of both phenomena stated above, a lower viscosity mixture of bitumen/EHO and solvent flows by gravity drainage to the producing well 5.
  • the solvent is injected into the upper injection well at or beyond the critical temperature of the solvent, as illustrated in Figure 2.
  • Figure 3 is a sketch of a physical model used to verify the superheated solvent recovery process according to an embodiment of the present invention.
  • a cannister 2 having the dimensions 10cm (a) x 80m (b) x 24cm (c) represents a small scale (1 :100) model of a 2-dimensional symmetry element of a reservoir perpendicular to a pair of injection and production wells 1 , 5.
  • the cannister was packed with sand and saturated with water and bitumen. The process was then carried out with butane being injected into the cannister at an injection temperature from 150°C to 260°C with high grade bitumen being recovered via the production well.
  • the results from the experiments carried out demonstrate the suitability of the process for the recovery of bitumen and extra heavy oil.
  • the process is capable of achieving high ultimate oil (bitumen) recoveries (approx. 80%) and the produced bitumen generally has an API 2-4 units higher than the original bitumen due to asphaltene precipitation in the model.
  • the physical experiments have been simulated with numerical reservoir simulators and reproduced with reasonable accuracy.
  • the up- scaled simulation results indicate that a production plant of 40,000 bbl/day would have a potential of an economy (NPV) that is better than SAGD and would use approx. 50- 67% of the energy used in SAGD.
  • NPV potential of an economy

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  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Physics & Mathematics (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Extraction Or Liquid Replacement (AREA)

Abstract

La présente invention concerne un procédé d'extraction d'hydrocarbures, tels que le bitume ou le pétrole brut extra-lourd, à partir d'une formation en roche mère d'hydrocarbures dans laquelle sont situés un puits supérieur d'injection et un puits inférieur de production. Ce procédé comporte les étapes suivantes: préchauffage d'une zone autour des puits et entre les puits, par circulation de solvant chaud dans l'intervalle réalisé entre chacun des puits, jusqu'à établir une communication hydraulique suffisante entre les deux puits; injection d'un ou de plusieurs solvants d'hydrocarbures dans le puits supérieur d'injection à une température au moins égale à la température critique du solvant ou du mélange de solvants, ce qui amène un mélange d'hydrocarbure et de solvant à s'écouler par drainage gravitaire vers le puits inférieur de production; et enfin, production de l'hydrocarbure vers la surface au travers du puits inférieur de production.
PCT/EP2011/051554 2010-02-04 2011-02-03 Procédé d'extraction par injection de solvant WO2011095542A2 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
US13/576,956 US9115577B2 (en) 2010-02-04 2011-02-03 Solvent injection recovery process
EA201290752A EA029061B1 (ru) 2010-02-04 2011-02-03 Способ добычи с нагнетанием растворителя
US14/801,088 US10190400B2 (en) 2010-02-04 2015-07-16 Solvent injection recovery process

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
CA2691889 2010-02-04
CA2691889A CA2691889C (fr) 2010-02-04 2010-02-04 Procede d'extraction par injection de solvants

Related Child Applications (2)

Application Number Title Priority Date Filing Date
US13/576,956 A-371-Of-International US9115577B2 (en) 2010-02-04 2011-02-03 Solvent injection recovery process
US14/801,088 Continuation US10190400B2 (en) 2010-02-04 2015-07-16 Solvent injection recovery process

Publications (2)

Publication Number Publication Date
WO2011095542A2 true WO2011095542A2 (fr) 2011-08-11
WO2011095542A3 WO2011095542A3 (fr) 2012-03-01

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US (2) US9115577B2 (fr)
CA (2) CA2691889C (fr)
EA (2) EA029061B1 (fr)
WO (1) WO2011095542A2 (fr)

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US10336520B2 (en) * 2016-04-15 2019-07-02 The Imagine Group, Llc Single-ply, non-corrugated materials suitable for decorative wrapping
CA2972203C (fr) 2017-06-29 2018-07-17 Exxonmobil Upstream Research Company Solvant de chasse destine aux procedes ameliores de recuperation
CA2974712C (fr) 2017-07-27 2018-09-25 Imperial Oil Resources Limited Methodes ameliorees de recuperation d'hydrocarbures visqueux d'une formation souterraine comme etape qui suit des procedes de recuperation thermique
CA2978157C (fr) 2017-08-31 2018-10-16 Exxonmobil Upstream Research Company Methodes de recuperation thermique servant a recuperer des hydrocarbures visqueux d'une formation souterraine
CA2983541C (fr) 2017-10-24 2019-01-22 Exxonmobil Upstream Research Company Systemes et methodes de surveillance et controle dynamiques de niveau de liquide
RU2683015C1 (ru) * 2018-03-12 2019-03-25 Общество с ограниченной ответственностью "Газпром проектирование" Способ разработки битуминозных аргиллитов и песчаников
US11821294B2 (en) * 2020-06-18 2023-11-21 Cenovus Energy Inc. Methods for recovering solvent and producing hydrocarbons from subterranean reservoirs

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Also Published As

Publication number Publication date
WO2011095542A3 (fr) 2012-03-01
CA2691889C (fr) 2016-05-17
US20150322758A1 (en) 2015-11-12
CA2730629C (fr) 2018-11-20
CA2730629A1 (fr) 2011-08-04
EA201290752A1 (ru) 2013-03-29
EA201792277A2 (ru) 2018-02-28
EA037125B1 (ru) 2021-02-09
US10190400B2 (en) 2019-01-29
EA201792277A3 (ru) 2018-05-31
US9115577B2 (en) 2015-08-25
EA029061B1 (ru) 2018-02-28
US20130000894A1 (en) 2013-01-03
CA2691889A1 (fr) 2011-08-04

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